System for lining a wellbore casing

ABSTRACT

A system for lining a wellbore casing includes a support member, an expansion device coupled to an end of the support member, and a tubular liner coupled to the expansion device. The tubular liner includes an expandable tubular member that includes a first tubular portion, a second tubular portion, and an intermediate tubular portion coupled between the first and second tubular portions. The expandable tubular member also includes a sealing member coupled to the exterior surface of the intermediate tubular portion.

CROSS REFERENCE TO RELATED APPLICATIONS

The present application is the National Stage filing for PCT patent application serial number PCT/US02/25727, filed on Aug. 14, 2002, which claimed the benefit of the filing dates of U.S. provisional patent application Ser. No. 60/317,985, filed on Sep. 6, 2001, and U.S. provisional patent application Ser. No. 60/318,386, filed on Sep. 10, 2001, the disclosures of which are incorporated herein by reference.

The present application is a continuation-in-part of U.S. utility patent application Ser. No. 10/030,593, filed on Jan. 8, 2002, which was the National Stage filing for PCT patent application serial number PCT/US00/18635, filed on Jul. 9, 2000, which claimed the benefit of the filing dates of U.S. provisional patent application Ser. No. 60/146,203, filed on Jul. 29, 1999, and U.S. provisional patent application Ser. No. 60/143,039, filed on Jul. 9, 1999, the disclosures of which are incorporated herein by reference.

The present application is related to the following: (1) U.S. Pat. No. 6,497,289, which was filed as U.S. patent application Ser. No. 09/454,139, filed on Dec. 3, 1999, which claims priority from provisional application 60/111,293, filed on Dec. 7, 1998, (2) U.S. patent application Ser. No. 09/510,913, filed on Feb. 23, 2000, which claims priority from provisional application 60/121,702, filed on Feb. 25, 1999, (3) U.S. patent application Ser. No. 09/502,350, filed on Feb. 10, 2000, which claims priority from provisional application 60/119,611, filed on Feb. 11, 1999, (4) U.S. Pat. No. 6,328,113, which was filed as U.S. patent application Ser. No. 09/440,338, filed on Nov. 15, 1999, which claims priority from provisional application 60/108,558, filed on Nov. 16, 1998, (5) U.S. patent application Ser. No. 10/169,434, filed on Jul. 1, 2002, which claims priority from provisional application 60/183,546, filed on Feb. 18, 2000, (6) U.S. Pat. No. 6,640,903 which was filed as U.S. patent application Ser. No. 09/523,468, filed on Mar. 10, 2000, which claims priority from provisional application 60/124,042, filed on Mar. 11, 1999, (7) U.S. Pat. No. 6,568,471, which was filed as patent application Ser. No. 09/512,895, filed on Feb. 24, 2000, which claims priority from provisional application 60/121,841, filed on Feb. 26, 1999, (8) U.S. Pat. No. 6,575,240, which was filed as patent application Ser. No. 09/511,941, filed on Feb. 24, 2000, which claims priority from provisional application 60/121,907, filed on Feb. 26, 1999, (9) U.S. Pat. No. 6,557,640, which was filed as patent application Ser. No. 09/588,946, filed on Jun. 7, 2000, which claims priority from provisional application 60/137,998, filed on Jun. 7, 1999, (10) U.S. patent application Ser. No. 09/981,916, filed on Oct. 18, 2001 as a continuation-in-part application of U.S. Pat. No. 6,328,113, which was filed as U.S. patent application Ser. No. 09/440,338, filed on Nov. 15, 1999, which claims priority from provisional application 60/108,558, filed on Nov. 16, 1998, (11) U.S. Pat. No. 6,604,763, which was filed as application Ser. No. 09/559,122, filed on Apr. 26, 2000, which claims priority from provisional application 60/131,106, filed on Apr. 26, 1999, (12) U.S. patent application Ser. No. 10/030,593, filed on Jan. 8, 2002, which claims priority from provisional application 60/146,203, filed on Jul. 29, 1999, (13) U.S. provisional patent application Ser. No. 60/143,039, filed on Jul. 9, 1999, (14) U.S. patent application Ser. No. 10/111,982, filed on Apr. 30, 2002, which claims priority from provisional patent application Ser. No. 60/162,671, filed on Nov. 1, 1999, (15) U.S. provisional patent application Ser. No. 60/154,047, filed on Sep. 16, 1999, (16) U.S. provisional patent application Ser. No. 60/438,828, filed on Jan. 9, 2003, (17) U.S. Pat. No. 6,564,875, which was filed as application Ser. No. 09/679,907, on Oct. 5, 2000, which claims priority from provisional patent application Ser. No. 60/159,082, filed on Oct. 12, 1999, (18) U.S. patent application Ser. No. 10/089,419, filed on Mar. 27, 2002, which claims priority from provisional patent application Ser. No. 60/159,039, filed on Oct. 12, 1999, (19) U.S. patent application Ser. No. 09/679,906, filed on Oct. 5, 2000, which claims priority from provisional patent application Ser. No. 60/159,033, filed on Oct. 12, 1999, (20) U.S. patent application Ser. No. 10/303,992, filed on Nov. 22, 2002, which claims priority from provisional patent application Ser. No. 60/212,359, filed on Jun. 19, 2000, (21) U.S. provisional patent application Ser. No. 60/165,228, filed on Nov. 12, 1999, (22) U.S. provisional patent application Ser. No. 60/455,051, filed on Mar. 14, 2003, (23) PCT application US02/2477, filed on Jun. 26, 2002, which claims priority from U.S. provisional patent application Ser. No. 60/303,711, filed on Jul. 6, 2001, (24) U.S. patent application Ser. No. 10/311,412, filed on Dec. 12, 2002, which claims priority from provisional patent application Ser. No. 60/221,443, filed on Jul. 28, 2000, (25) U.S. patent application Ser. No. 10/322,947, filed on Dec. 18, 2002, which claims priority from provisional patent application Ser. No. 60/221,645, filed on Jul. 28, 2000, (26) U.S. patent application Ser. No. 10/322,947, filed on Jan. 22, 2003, which claims priority from provisional patent application Ser. No. 60/233,638, filed on Sep. 18, 2000, (27) U.S. patent application Ser. No. 10/406,648, filed on Mar. 31, 2003, which claims priority from provisional patent application Ser. No. 60/237,334, filed on Oct. 2, 2000, (28) PCT application US02/04353, filed on Feb. 14, 2002, which claims priority from U.S. provisional patent application Ser. No. 60/270,007, filed on Feb. 20, 2001, (29) U.S. patent application Ser. No. 10/465,835, filed on Jun. 13, 2003, which claims priority from provisional patent application Ser. No. 60/262,434, filed on Jan. 17, 2001, (30) U.S. patent application Ser. No. 10/465,831, filed on Jun. 13, 2003, which claims priority from U.S. provisional patent application Ser. No. 60/259,486, filed on Jan. 3, 2001, (31) U.S. provisional patent application Ser. No. 60/452,303, filed on Mar. 5, 2003, (32) U.S. Pat. No. 6,470,966, which was filed as patent application Ser. No. 09/850,093, filed on May 7, 2001, as a divisional application of U.S. Pat. No. 6,497,289, which was filed as U.S. patent application Ser. No. 09/454,139, filed on Dec. 3, 1999, which claims priority from provisional application 60/111,293, filed on Dec. 7, 1998, (33) U.S. Pat. No. 6,561,227, which was filed as patent application Ser. No. 09/852,026, filed on May 9, 2001, as a divisional application of U.S. Pat. No. 6,497,289, which was filed as U.S. patent application Ser. No. 09/454,139, filed on Dec. 3, 1999, which claims priority from provisional application 60/111,293, filed on Dec. 7, 1998, (34) U.S. patent application Ser. No. 09/852,027, filed on May 9, 2001, as a divisional application of U.S. Pat. No. 6,497,289, which was filed as U.S. patent application Ser. No. 09/454,139, filed on Dec. 3, 1999, which claims priority from provisional application 60/111,293, filed on Dec. 7, 1998, (35) PCT Application US02/25608, filed on Aug. 13, 2002, which claims priority from provisional application 60/318,021, filed on Sep. 7, 2001, (36) PCT Application US02/24399, filed on Aug. 1, 2002, which claims priority from U.S. provisional patent application Ser. No. 60/313,453, filed on Aug. 20, 2001, (37) PCT Application US02/29856, filed on Sep. 19, 2002, which claims priority from U.S. provisional patent application Ser. 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No. 09/523,468, filed on Mar. 10, 2000, (now U.S. Pat. No. 6,640,903 which issued Nov. 4, 2003), which claims priority from provisional application 60/124,042, filed on Mar. 11, 1999, (42) U.S. patent application Ser. No. 09/962,467, filed on Sep. 25, 2001, which is a divisional of U.S. patent application Ser. No. 09/523,468, filed on Mar. 10, 2000, (now U.S. Pat. No. 6,640,903 which issued Nov. 4, 2003), which claims priority from provisional application 60/124,042, filed on Mar. 11, 1999, (43) U.S. patent application Ser. No. 09/962,468, filed on Sep. 25, 2001, which is a divisional of U.S. patent application Ser. No. 09/523,468, filed on Mar. 10, 2000, (now U.S. Pat. No. 6,640,903 which issued Nov. 4, 2003), which claims priority from provisional application 60/124,042, filed on Mar. 11, 1999, (44) PCT application US 02/25727, filed on Aug. 14, 2002, which claims priority from U.S. provisional patent application Ser. No. 60/317,985, filed on Sep. 6, 2001, and U.S. provisional patent application Ser. No. 60/318,386, filed on Sep. 10, 2001, (45) PCT application US 02/39425, filed on Dec. 10, 2002, which claims priority from U.S. provisional patent application Ser. No. 60/343,674, filed on Dec. 27, 2001, (46) U.S. utility patent application Ser. No. 09/969,922, filed on Oct. 3, 2001, (now U.S. Pat. No. 6,634,431 which issued Oct. 21, 2003), which is a continuation-in-part application of U.S. Pat. No. 6,328,113, which was filed as U.S. patent application Ser. No. 09/440,338, filed on Nov. 15, 1999, which claims priority from provisional application 60/108,558, filed on Nov. 16, 1998, (47) U.S. utility patent application Ser. No. 10/516,467, filed on Dec. 10, 2001, which is a continuation application of U.S. utility patent application Ser. No. 09/969,922, filed on Oct. 3, 2001, (now U.S. Pat. No. 6,634,431 which issued Oct. 21, 2003), which is a continuation-in-part application of U.S. Pat. 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This application is related to the following (1) PCT patent application Ser. No. PCT/US2004/06246, filed on Feb. 26, 2004; (2) PCT patent application Ser. No. PCT/US2004/08170, filed on Mar. 15, 2004; (3) PCT patent application Ser. No. PCT/US2004/08171, filed on Mar. 15, 2004; (4) PCT patent application Ser. No. PCT/US2004/08073, filed on Mar. 18, 2004; (5) PCT patent application Ser. No. PCT/US2004/07711. filed on Mar. 11, 2004; (6) PCT patent application Ser. No. PCT/US2004/029025, filed on Mar. 26, 2004; (7) PCT patent application Ser. No. PCT/US2004/010317, filed on Apr. 2, 2004; (8) PCT patent application Ser. No. PCT/US2004/010712, filed on Apr. 6, 2004; (9) PCT patent application Ser. No. PCT/US2004/010762, filed on Apr. 6, 2004; (10) PCT patent application Ser. No. PCT/US2004/011973, filed on Apr. 15, 2004; (11) U.S. provisional patent application Ser. No. 60/495,056, filed on Aug. 14, 2003; (12) U.S. provisional patent application Ser. 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BACKGROUND

This invention relates generally to wellbore casings, and in particular to wellbore casings that are formed using expandable tubing.

Conventionally, when a wellbore is created, a number of casings are installed in the borehole to prevent collapse of the borehole wall and to prevent undesired outflow of drilling fluid into the formation or inflow of fluid from the formation into the borehole. The borehole is drilled in intervals whereby a casing which is to be installed in a lower borehole interval is lowered through a previously installed casing of an upper borehole interval. As a consequence of this procedure the casing of the lower interval is of smaller diameter than the casing of the upper interval. Thus, the casings are in a nested arrangement with casing diameters decreasing in downward direction. Cement annuli are provided between the outer surfaces of the casings and the borehole wall to seal the casings from the borehole wall. As a consequence of this nested arrangement a relatively large borehole diameter is required at the upper part of the wellbore. Such a large borehole diameter involves increased costs due to heavy casing handling equipment, large drill bits and increased volumes of drilling fluid and drill cuttings. Moreover, increased drilling rig time is involved due to required cement pumping, cement hardening, required equipment changes due to large variations in hole diameters drilled in the course of the well, and the large volume of cuttings drilled and removed.

The present invention is directed to overcoming one or more of the limitations of the existing procedures for forming wellbore casings.

SUMMARY

According to one aspect of the present invention, a system for lining a wellbore casing is provided that includes a tubular support member defining a first passage, a tubular expansion cone defining a second passage fluidicly coupled to the first passage coupled to an end of the tubular support member and comprising a tapered end, a tubular liner coupled to and supported by the tapered end of the tubular expansion cone, and a shoe defining a valveable passage coupled to an end of the tubular liner, wherein the tubular liner includes one or more expandable tubular members that each include a tubular body comprising an intermediate portion and first and second expanded end portions coupled to opposing ends of the intermediate portion, and a sealing member coupled to the exterior surface of the intermediate portion, and one or more other tubular members coupled to the expandable tubular members, wherein the inside diameters of the other tubular members are greater than or equal to the outside diameter of the tubular expansion cone.

According to another aspect of the present invention, a method of lining a wellbore casing is provided that includes positioning a tubular liner within the wellbore casing, and radially expanding one or more discrete portions of the tubular liner into engagement with the wellbore casing.

According to another aspect of the present invention, a system for lining a wellbore casing is provided that includes means for positioning a tubular liner within the wellbore casing, and means for radially expanding one or more discrete portions of the tubular liner into engagement with the wellbore casing. In an exemplary embodiment, a plurality of discrete portions of the tubular liner are radially expanded into engagement with the wellbore casing.

According to another aspect of the present invention, an apparatus is provided that includes a subterranean formation defining a borehole, a casing positioned in and coupled to the borehole, and a tubular liner positioned in and coupled to the casing at one or more discrete locations.

BRIEF DESCRIPTION OF THE DRAWINGS

FIG. 1 a is a cross sectional illustration of the placement of an illustrative embodiment of a system for lining a wellbore casing within a borehole having a preexisting wellbore casing.

FIG. 1 b is a cross sectional illustration of the system of FIG. 1 a during the injection of a fluidic material into the tubular support member.

FIG. 1 c is a cross sectional illustration of the system of FIG. 1 b during the pressurization of the interior portion of the shoe after sealing off the valveable fluid passage of the shoe.

FIG. 1 d is a cross sectional illustration of the system of FIG. 1 c during the continued injection of the fluidic material into the tubular support member.

FIG. 1 e is a cross sectional illustration of the system of FIG. 1 d after the completion of the radial expansion and plastic deformation of the expandable tubular members.

FIG. 1 f is a cross sectional illustration of the system of FIG. 1 e after machining the bottom central portion of the shoe.

FIG. 2 is a cross sectional illustration of an illustrative embodiment of the expandable tubular members of the system of FIG. 1 a.

FIG. 3 is a flow chart illustration of an illustrative embodiment of a method for manufacturing the expandable tubular member of FIG. 2.

FIG. 4 a is a cross sectional illustration of an illustrative embodiment of the upsetting of the ends of a tubular member.

FIG. 4 b is a cross sectional illustration of the expandable tubular member of FIG. 4 a after radially expanding and plastically deforming the ends of the expandable tubular member.

FIG. 4 c is a cross sectional illustration of the expandable tubular member of FIG. 4 b after forming threaded connections on the ends of the expandable tubular member.

FIG. 4 d is a cross sectional illustration of the expandable tubular member of FIG. 4 c after coupling sealing members to the exterior surface of the intermediate unexpanded portion of the expandable tubular member.

FIG. 5 is a cross-sectional illustration of an exemplary embodiment of a tubular expansion cone.

FIG. 6 is a cross-sectional illustration of an exemplary embodiment of a tubular expansion cone.

DESCRIPTION OF THE ILLUSTRATIVE EMBODIMENTS

Referring initially to FIG. 1 a, the reference numeral 10 refers, in general, to a system for lining a wellbore casing that includes a tubular support member 12 that defines a passage 12 a. A tubular expansion cone 14 that defines a passage 14 a is coupled to an end of the tubular support member 12. In an exemplary embodiment, the tubular expansion cone 14 includes a tapered outer surface 14 b for reasons to be described. A pre-expanded end 16 a of a first expandable tubular member 16 that defines a passage 16 b is adapted to mate with and be supported by the tapered outer surface 14 b of the tubular expansion cone 14. The first expandable tubular member 16 further includes an unexpanded intermediate portion 16 c, another pre-expanded end 16 d, and a sealing member 16 e coupled to the exterior surface of the unexpanded intermediate portion. In an exemplary embodiment, the inside and outside diameters of the pre-expanded ends, 16 a and 16 d, of the first expandable tubular member 16 are greater than the inside and outside diameters of the unexpanded intermediate portion 16 c. An end 18 a of a shoe 18 that defines a passage 18 b and a valveable passage 18 c is coupled to the pre-expanded end 16 a of the first expandable tubular member 16 by a conventional threaded connection.

An end 20 a of a tubular member 20 that defines a passage 20 b is coupled to the other pre-expanded end 16 d of the first expandable tubular member 16 by a conventional threaded connection. Another end 20 c of the tubular member 20 is coupled to an end 22 a of a tubular member 22 that defines a passage 22 b by a conventional threaded connection. A pre-expanded end 24 a of a second expandable tubular member 24 that defines a passage 24 b is coupled to the other end 22 c of the tubular member 22. The second expandable tubular member 24 further includes an unexpanded intermediate portion 24 c, another pre-expanded end 24 d, and a sealing member 24 e coupled to the exterior surface of the unexpanded intermediate portion. In an exemplary embodiment, the inside and outside diameters of the pre-expanded ends, 24 a and 24 d, of the second expandable tubular member 24 are greater than the inside and outside diameters of the unexpanded intermediate portion 24 c.

An end 26 a of a tubular member 26 that defines a passage 26 b is coupled to the other pre-expanded end 24 d of the second expandable tubular member 24 by a conventional threaded connection. Another end 26 c of the tubular member 26 is coupled to an end 28 a of a tubular member 28 that defines a passage 28 b by a conventional threaded connection. A pre-expanded end 30 a of a third expandable tubular member 30 that defines a passage 30 b is coupled to the other end 28 c of the tubular member 28. The third expandable tubular member 30 further includes an unexpanded intermediate portion 30 c, another pre-expanded end 30 d, and a sealing member 30 e coupled to the exterior surface of the unexpanded intermediate portion. In an exemplary embodiment, the inside and outside diameters of the pre-expanded ends, 30 a and 30 d, of the third expandable tubular member 30 are greater than the inside and outside diameters of the unexpanded intermediate portion 30 c.

In an exemplary embodiment, the inside and outside diameters of the pre-expanded ends, 16 a, 16 d, 24 a, 24 d, 30 a and 30 d, of the expandable tubular members, 16, 24, and 30, and the tubular members 20, 22, 26, and 28, are substantially equal. In several exemplary embodiments, the sealing members, 16 e, 24 e, and 30 e, of the expandable tubular members, 16, 24, and 30, respectively, further include anchoring elements for engaging the wellbore casing 104. In several exemplary embodiments, the tubular members, 20, 22, 26, and 28, are conventional tubular members having threaded end connections suitable for use in an oil or gas well, an underground pipeline, or as a structural support.

In an exemplary embodiment, as illustrated in FIG. 1 a, the system 10 is initially positioned in a borehole 100 formed in a subterranean formation 102 that includes a pre-existing wellbore casing 104. The borehole 100 may be positioned in any orientation from vertical to horizontal. Furthermore, the wellbore casing 104 may be, for example, a wellbore casing for an oil or gas well, an underground pipeline, or a structural support. In an exemplary embodiment, the upper end of the tubular support member 12 may be supported in a conventional manner using, for example, a slip joint, or equivalent device in order to permit upward movement of the tubular support member and tubular expansion cone 14 relative to one or more of the expandable tubular members, 16, 24, and 30, and tubular members, 20, 22, 26, and 28.

In an exemplary embodiment, as illustrated in FIG. 1 b, a fluidic material 106 is then injected into the system 10, through the passages, 12 a and 14 a, of the tubular support member 12 and tubular expansion cone 14, respectively. The fluidic material 106 then passes into the passages, 18 b and 18 c, of the shoe 18 into the borehole 100.

In an exemplary embodiment, as illustrated in FIG. 1 c, a ball 108, plug or other equivalent device is then introduced into the injected fluidic material 106. The ball 108 will then pass through the passages, 12 a, 14 a, and 18 b, of the tubular support member 12, the tubular expansion cone 14, and the shoe 18, respectively, and will then be positioned within the valveable passage 18 c of the shoe. In this manner, the valveable passage 18 c of the shoe 18 is closed thereby permitting the passage 18 b of the shoe below the tubular expansion cone 14 to be pressurized by the continued injection of the fluidic material 106.

In an exemplary embodiment, as illustrated in FIG. 1 d, the continued injection of the fluidic material 106 through the passages, 12 a and 14 a, of the tubular support member 12 and the tubular expansion cone 14, respectively, pressurizes the passage 18 b of the shoe 18 below the tubular expansion cone thereby radially expanding and plastically deforming the expandable tubular member 16 off of the tapered external surface 14 b of the tubular expansion cone 14. In particular, the intermediate non pre-expanded portion 16 c of the expandable tubular member 16 is radially expanded and plastically deformed off of the tapered external surface 14 b of the tubular expansion cone 14. As a result, the sealing member 16 e engages the interior surface of the wellbore casing 104. Consequently, the radially expanded intermediate portion 16 c of the expandable tubular member 16 is thereby coupled to the wellbore casing 104. In an exemplary embodiment, the radially expanded intermediate portion 16 c of the expandable tubular member 16 is also thereby anchored to the wellbore casing 104.

The continued injection of the fluidic material 106 through the passages, 12 a and 14 a, of the tubular support member 12 and the tubular expansion cone 14, respectively, will then displace the tubular expansion cone 14 upwardly into engagement with the pre-expanded end 24 a of the second expandable tubular member 24.

In an exemplary embodiment, as illustrated in FIG. 1 e, the continued injection of the fluidic material 106 through the passages, 12 a and 14 a, of the tubular support member 12 and tubular expansion cone 14, respectively, will then pressurize the passages 18 b, 16 b, 20 b and 22 b below the tubular expansion cone thereby radially expanding and plastically deforming the second expandable tubular member 24 off of the tapered external surface 14 b of the tubular expansion cone 14. In particular, the intermediate non pre-expanded portion 24 c of the second expandable tubular member 24 is radially expanded and plastically deformed off of the tapered external surface 14 b of the tubular expansion cone 14. As a result, the sealing member 24 e engages the interior surface of the wellbore casing 104. Consequently, the radially expanded intermediate portion 24 c of the second expandable tubular member 24 is thereby coupled to the wellbore casing 104. In an exemplary embodiment, the radially expanded intermediate portion 24 c of the second expandable tubular member 24 is also thereby anchored to the wellbore casing 104.

The continued injection of the fluidic material 106 through the passages, 12 a and 14 a, of the tubular support member 12 and the tubular expansion cone 14, respectively, will then displace the tubular expansion cone 14 upwardly into engagement with the pre-expanded end 30 a of the third expandable tubular member 30.

The continued injection of the fluidic material 106 through the passages, 12 a and 14 a, of the tubular support member 12 and tubular expansion cone 14, respectively, will then pressurize the passages 18 b, 16 b, 20 b, 22 b, 24 b, 26 b, and 28 b below the tubular expansion cone thereby radially expanding and plastically deforming the third expandable tubular member 30 off of the tapered external surface 14 b of the tubular expansion cone 14. In particular, the intermediate non pre-expanded portion 30 c of the third expandable tubular member 30 is radially expanded and plastically deformed off of the tapered external surface 14 b of the tubular expansion cone 14. As a result, the sealing member 30 e engages the interior surface of the wellbore casing 104. Consequently, the radially expanded intermediate portion 30 c of the third expandable tubular member 30 is thereby coupled to the wellbore casing 104. In an exemplary embodiment, the radially expanded intermediate portion 30 c of the third expandable tubular member 30 is also thereby anchored to the wellbore casing 104.

In an exemplary embodiment, during the injection of the fluidic material 106 through the passages, 12 a and 14 a, of the tubular support member 12 and the tubular expansion cone 14, respectively, the tubular support member 12 and tubular expansion cone 14 are displaced upwardly relative to the expandable tubular members, 16, 24, and 30, and the tubular members, 20, 22, 26, and 28, by applying an upward axial force to the upper end of the tubular support member.

After completing the radial expansion and plastic deformation of the third expandable tubular member 30, the tubular support member 12 and the tubular expansion cone 14 are removed from the wellbore 100.

In an exemplary embodiment, as illustrated in FIG. 1 f, the lower central portion of the shoe 18 is then removed using a conventional milling device.

Thus, during the operation of the system 10, the intermediate non pre-expanded portions, 16 c, 24 c, and 30 c, of the expandable tubular members, 16, 24, and 30, respectively, are radially expanded and plastically deformed by the pressurization of the interior passages, 18 a, 16 b, 20 b, 22 b, 24 b, 26 b, 28 b, and 30 b, of the shoe 18, the expandable tubular member 16, the tubular members, 20 and 22, the expandable tubular member 24, the tubular members, 26 and 28, and the expandable tubular member 30, respectively, below the tubular expansion cone 14. As a result, the sealing members, 16 e, 24 e, and 30 e, are displaced in the radial direction into engagement with the wellbore casing 104 thereby coupling the shoe 18, the expandable tubular member 16, the tubular members, 20 and 22, the expandable tubular member 24, the tubular members, 26 and 28, and the expandable tubular member 30 to the wellbore casing. Furthermore, as a result, the expandable connections between the expandable tubular members, 16, 24, and 30, the shoe 18, and the tubular members, 20, 22, 26, and 28, do not have to be expandable connections thereby providing significant cost savings. Furthermore, in the system 10, the tubular members 20, 22, 26, and 28 are interleaved among the expandable tubular members, 16, 24, and 30. As a result, because only the intermediate non pre-expanded portions, 16 c, 24 c, and 30 c, of the expandable tubular members, 16, 24, and 30, respectively, are radially expanded and plastically deformed, the tubular members, 20, 22, 26, and 28 can be conventional tubular members thereby significantly reducing the cost and complexity of the system 10. Moreover, because only the intermediate non pre-expanded portions, 16 c, 24 c, and 30 c, of the expandable tubular members, 16, 24, and 30, respectively, are radially expanded and plastically deformed, the number and length of the interleaved tubular members, 20, 22, 26, and 28 can be much greater than the number and length of the expandable tubular members. In an exemplary embodiment, the total length of the intermediate non pre-expanded portions, 16 c, 24 c, and 30 c, of the expandable tubular members, 16, 24, and 30, is approximately 200 feet, and the total length of the tubular members, 20, 22, 26, and 28, is approximately 3800 feet. Consequently, in an exemplary embodiment, a liner having a total length of approximately 4000 feet is coupled to a wellbore casing by radially expanding and plastically deforming a total length of only approximately 200 feet.

Furthermore, the sealing members 16 e, 24 e, and 30 e, of the expandable tubular members, 16, 24, and 30, respectively, are used to couple the expandable tubular members and the tubular members, 20, 22, 26, and 28 to the wellbore casing 104, the radial gap between the tubular members, the expandable tubular members, and the wellbore casing 104 may be large enough to effectively eliminate the possibility of damage to the expandable tubular members and tubular members during the placement of the system 10 within the wellbore casing.

In an exemplary embodiment, after the sealing member 16 e of the expandable tubular member 16 has been radially expanded into engagement with the wellbore casing 104, the expandable tubular members, 24 and 30, are radially expanded and plastically deformed by injecting the fluidic material 106 and applying an upward axial force to the tubular support member 12 and tubular expansion cone 14. In this manner, radial expansion and plastic deformation of the expandable tubular members, 24 and 30, may be enhanced.

In an exemplary embodiment, after the sealing member 16 e of the expandable tubular member 16 has been radially expanded into engagement with the wellbore casing 104, the expandable tubular members, 24 and 30, are radially expanded and plastically deformed by only applying an upward axial force to the tubular support member 12 and tubular expansion cone 14. In this manner, radial expansion and plastic deformation of the expandable tubular members, 24 and 30, may be provided without the further continued injection of the fluidic material 106.

In an exemplary embodiment, the pre-expanded ends, 16 a, 16 d, 24 a, 24 d, 30 a, and 30 d, of the expandable tubular members, 16, 24, and 30, respectively, and the tubular members, 20, 22, 26, and 28, have outside diameters and wall thicknesses of 8.375 inches and 0.350 inches, respectively; prior to the radial expansion, the intermediate non pre-expanded portions, 16 c, 24 c, and 30 c, of the expandable tubular members, 16, 24, and 30, respectively, have outside diameters of 7.625 inches; the tubular members, 20, 22, 26, and 28, have inside diameters of 7.675 inches; after the radial expansion, the inside diameters of the intermediate portions, 16 c, 24 c, and 30 c, of the expandable tubular members, 16, 24, and 30, are equal to 7.675 inches; and the wellbore casing 104 has an inside diameter of 8.755 inches.

In an exemplary embodiment, the pre-expanded ends, 16 a, 16 d, 24 a, 24 d, 30 a, and 30 d, of the expandable tubular members, 16, 24, and 30, respectively, and the tubular members, 20, 22, 26, and 28, have outside diameters and wall thicknesses of 4.500 inches and 0.250 inches, respectively; prior to the radial expansion, the intermediate non pre-expanded portions, 16 c, 24 c, and 30 c, of the expandable tubular members, 16, 24, and 30, respectively, have outside diameters of 4.000 inches; the tubular members, 20, 22, 26, and 28, have inside diameters of 4.000 inches; after the radial expansion, the inside diameters of the intermediate portions, 16 c, 24 c, and 30 c, of the expandable tubular members, 16, 24, and 30, are equal to 4.000 inches; and the wellbore casing 104 has an inside diameter of 4.892 inches.

In an exemplary embodiment, the system 10 is used to form or repair a wellbore casing, a pipeline, or a structural support.

Referring now to FIG. 2, an exemplary embodiment of an expandable tubular member 200 will now be described. The tubular member 200 defines an interior region 200 a and includes a first end 200 b including a first threaded connection 200 ba, a first tapered portion 200 c, an intermediate portion 200 d, a second tapered portion 200 e, and a second end 200 f including a second threaded connection 200 fa. The tubular member 200 further preferably includes an intermediate sealing member 200 g that is coupled to the exterior surface of the intermediate portion 200 d.

In an exemplary embodiment, the tubular member 200 has a substantially annular cross section. The tubular member 200 may be fabricated from any number of conventional commercially available materials such as, for example, Oilfield Country Tubular Goods (OCTG), 13 chromium steel tubing/casing, or L83, J55, or P110 API casing.

In an exemplary embodiment, the interior 200 a of the tubular member 200 has a substantially circular cross section. Furthermore, in an exemplary embodiment, the interior region 200 a of the tubular member includes a first inside diameter D₁, an intermediate inside diameter D_(INT), and a second inside diameter D₂. In an exemplary embodiment, the first and second inside diameters, D₁ and D₂, are substantially equal. In an exemplary embodiment, the first and second inside diameters, D₁ and D₂, are greater than the intermediate inside diameter D_(INT).

The first end 200 b of the tubular member 200 is coupled to the intermediate portion 200 d by the first tapered portion 200 c, and the second end 200 f of the tubular member is coupled to the intermediate portion by the second tapered portion 200 e. In an exemplary embodiment, the outside diameters of the first and second ends, 200 b and 200 f, of the tubular member 200 is greater than the outside diameter of the intermediate portion 200 d of the tubular member. The first and second ends, 200 b and 200 f, of the tubular member 200 include wall thicknesses, t₁ and t₂, respectively. In an exemplary embodiment, the outside diameter of the intermediate portion 200 d of the tubular member 200 ranges from about 75% to 98% of the outside diameters of the first and second ends, 200 a and 200 f. The intermediate portion 200 d of the tubular member 200 includes a wall thickness t_(INT).

In an exemplary embodiment, the wall thicknesses t₁ and t₂ are substantially equal in order to provide substantially equal burst strength for the first and second ends, 200 a and 200 f, of the tubular member 200. In an exemplary embodiment, the wall thicknesses, t₁ and t₂, are both greater than the wall thickness t_(INT) in order to optimally match the burst strength of the first and second ends, 200 a and 200 f, of the tubular member 200 with the intermediate portion 200 d of the tubular member 200.

In an exemplary embodiment, the first and second tapered portions, 200 c and 200 e, are inclined at an angle, α, relative to the longitudinal direction ranging from about 0 to 30 degrees in order to optimally facilitate the radial expansion of the tubular member 200. In an exemplary embodiment, the first and second tapered portions, 200 c and 200 e, provide a smooth transition between the first and second ends, 200 a and 200 f, and the intermediate portion 200 d, of the tubular member 200 in order to minimize stress concentrations.

The intermediate sealing member 200 g is coupled to the outer surface of the intermediate portion 200 d of the tubular member 200. In an exemplary embodiment, the intermediate sealing member 200 g seals the interface between the intermediate portion 200 d of the tubular member 200 and the interior surface of a wellbore casing 205 after the radial expansion and plastic deformation of the intermediate portion 200 d of the tubular member 200. In an exemplary embodiment, the intermediate sealing member 200 g has a substantially annular cross section. In an exemplary embodiment, the outside diameter of the intermediate sealing member 200 g is selected to be less than the outside diameters of the first and second ends, 200 a and 200 f, of the tubular member 200 in order to, optimally protect the intermediate sealing member 200 g during placement of the tubular member 200 within the wellbore casings 205. The intermediate sealing member 200 g may be fabricated from any number of conventional commercially available materials such as, for example, thermoset or thermoplastic polymers. In an exemplary embodiment, the intermediate sealing member 200 g is fabricated from thermoset polymers in order to optimally seal the radially expanded intermediate portion 200 d of the tubular member 200 with the wellbore casing 205. In several alternative embodiments, the sealing member 200 g includes one or more rigid anchors for engaging the wellbore casing 205 to thereby anchor the radially expanded and plastically deformed intermediate portion 200 d of the tubular member 200 to the wellbore casing.

Referring to FIGS. 3, and 4 a to 4 d, in an exemplary embodiment, the tubular member 200 is formed by a process 300 that includes the steps of: (1) upsetting both ends of a tubular member in step 305; (2) expanding both upset ends of the tubular member in step 310; (3) stress relieving both expanded upset ends of the tubular member in step 315; (4) forming threaded connections in both expanded upset ends of the tubular member in step 320; and (5) putting a sealing material on the outside diameter of the non-expanded intermediate portion of the tubular member in step 325.

As illustrated in FIG. 4 a, in step 305, both ends, 400 a and 400 b, of a tubular member 400 are upset using conventional upsetting methods. The upset ends, 400 a and 400 b, of the tubular member 400 include the wall thicknesses t₁ and t₂. The intermediate portion 400 c of the tubular member 400 includes the wall thickness t_(INT) and the interior diameter D_(INT). In an exemplary embodiment, the wall thicknesses t₁ and t₂ are substantially equal in order to provide burst strength that is substantially equal along the entire length of the tubular member 400. In an exemplary embodiment, the wall thicknesses t₁ and t₂ are both greater than the wall thickness t_(INT) in order to provide burst strength that is substantially equal along the entire length of the tubular member 400, and also to optimally facilitate the formation of threaded connections in the first and second ends, 400 a and 400 b.

As illustrated in FIG. 4 b, in steps 310 and 315, both ends, 400 a and 400 b, of the tubular member 400 are radially expanded using conventional radial expansion methods, and then both ends, 400 a and 400 b, of the tubular member are stress relieved. The radially expanded ends, 400 a and 400 b, of the tubular member 400 include the interior diameters D₁ and D₂. In an exemplary embodiment, the interior diameters D₁ and D₂ are substantially equal in order to provide a burst strength that is substantially equal. In an exemplary embodiment, the ratio of the interior diameters D₁ and D₂ to the interior diameter D_(INT) ranges from about 100% to 120% in order to faciliate the subsequent radial expansion of the tubular member 400.

In a preferred embodiment, the relationship between the wall thicknesses t₁, t₂, and t_(INT) of the tubular member 400; the inside diameters D₁, D₂ and D_(INT) of the tubular member 400; the inside diameter D_(wellbore) of the wellbore casing that the tubular member 400 will be inserted into; and the outside diameter D_(cone) of the expansion cone that will be used to radially expand the tubular member 400 within the wellbore casing is given by the following expression:

$\begin{matrix} {{{Dwellbore} - {2*t_{1}}} \geq D_{1} \geq {\frac{1}{t_{1}}\left\lbrack {{\left( {t_{1} - t_{INT}} \right)*D_{cone}} + {t_{INT}*D_{INT}}} \right\rbrack}} & (1) \end{matrix}$ where t₁=t₂; and

-   D₁=D₂.

By satisfying the relationship given in equation (1), the expansion forces placed upon the tubular member 400 during the subsequent radial expansion process are substantially equalized. More generally, the relationship given in equation (1) may be used to calculate the optimal geometry for the tubular member 400 for subsequent radial expansion and plastic deformation of the tubular member 400 for fabricating and/or repairing a wellbore casing, a pipeline, or a structural support.

As illustrated in FIG. 4 c, in step 320, conventional threaded connections, 400 d and 400 e, are formed in both expanded ends, 400 a and 400 b, of the tubular member 400. In an exemplary embodiment, the threaded connections, 400 d and 400 e, are provided using conventional processes for forming pin and box type threaded connections available from Atlas-Bradford.

As illustrated in FIG. 4 d, in step 325, a sealing member 400 f is then applied onto the outside diameter of the non-expanded intermediate portion 400 c of the tubular member 400. The sealing member 400 f may be applied to the outside diameter of the non-expanded intermediate portion 400 c of the tubular member 400 using any number of conventional commercially available methods. In a preferred embodiment, the sealing member 400 f is applied to the outside diameter of the intermediate portion 400 c of the tubular member 400 using commercially available chemical and temperature resistant adhesive bonding.

In an exemplary embodiment, the expandable tubular members, 16, 24, and 30, of the system 10 are substantially identical to, and/or incorporate one or more of the teachings of, the tubular members 200 and 400.

Referring to FIG. 5, an exemplary embodiment of tubular expansion cone 500 for radially expanding the tubular members 16, 24, 30, 200 and 400 will now be described. The expansion cone 500 defines a passage 500 a and includes a front end 505, a rear end 510, and a radial expansion section 515.

In an exemplary embodiment, the radial expansion section 515 includes a first conical outer surface 520 and a second conical outer surface 525. The first conical outer surface 520 includes an angle of attack α₁ and the second conical outer surface 525 includes an angle of attack α₂. In an exemplary embodiment, the angle of attack α₁ is greater than the angle of attack α₂. In this manner, the first conical outer surface 520 radially overexpands the intermediate portions, 16 c, 24 c, 30 c, 200 d, and 400 c, of the tubular members, 16, 24, 30, 200, and 400, and the second conical outer surface 525 radially overexpands the pre-expanded first and second ends, 16 a and 16 d, 24 a and 24 d, 30 a and 30 d, 200 b and 200 f, and 400 a and 400 b, of the tubular members, 16, 24, 30, 200 and 400. In an exemplary embodiment, the first conical outer surface 520 includes an angle of attack α₁ ranging from about 8 to 20 degrees, and the second conical outer surface 525 includes an angle of attack α₂ ranging from about 4 to 15 degrees in order to optimally radially expand and plastically deform the tubular members, 16, 24, 30, 200 and 400. More generally, the expansion cone 500 may include 3 or more adjacent conical outer surfaces having angles of attack that decrease from the front end 505 of the expansion cone 500 to the rear end 510 of the expansion cone 500.

Referring to FIG. 6, another exemplary embodiment of a tubular expansion cone 600 defines a passage 600 a and includes a front end 605, a rear end 610, and a radial expansion section 615. In an exemplary embodiment, the radial expansion section 615 includes an outer surface having a substantially parabolic outer profile thereby providing a paraboloid shape. In this manner, the outer surface of the radial expansion section 615 provides an angle of attack that constantly decreases from a maximum at the front end 605 of the expansion cone 600 to a minimum at the rear end 610 of the expansion cone. The parabolic outer profile of the outer surface of the radial expansion section 615 may be formed using a plurality of adjacent discrete conical sections and/or using a continuous curved surface. In this manner, the region of the outer surface of the radial expansion section 615 adjacent to the front end 605 of the expansion cone 600 may optimally radially overexpand the intermediate portions, 16 c, 24 c, 30 c, 200 d, and 400 c, of the tubular members, 16, 24, 30, 200, and 400, while the region of the outer surface of the radial expansion section 615 adjacent to the rear end 610 of the expansion cone 600 may optimally radially overexpand the pre-expanded first and second ends, 16 a and 16 d, 24 a and 24 d, 30 a and 30 d, 200 b and 200 f, and 400 a and 400 b, of the tubular members, 16, 24, 30, 200 and 400. In an exemplary embodiment, the parabolic profile of the outer surface of the radial expansion section 615 is selected to provide an angle of attack that ranges from about 8 to 20 degrees in the vicinity of the front end 605 of the expansion cone 6800 and an angle of attack in the vicinity of the rear end 610 of the expansion cone 600 from about 4 to 15 degrees.

In an exemplary embodiment, the tubular expansion cone 14 of the system 10 is substantially identical to the expansion cones 500 or 600, and/or incorporates one or more of the teachings of the expansion cones 500 and/or 600.

In several alternative embodiments, a conventional rotary expansion system such as, for example, those commercially available from Weatherford International may be substituted for, or used in combination with the expansion cones 14, 500, and/or 600 above.

In several alternative embodiments, conventional expansion systems may be substituted for, or used in combination with the expansion cones 14, 500, and/or 600 above.

A system for lining a wellbore casing has been described that includes a tubular support member defining a first passage, a tubular expansion cone defining a second passage fluidicly coupled to the first passage coupled to an end of the tubular support member and comprising a tapered end, a tubular liner coupled to and supported by the tapered end of the tubular expansion cone, and a shoe defining a valveable passage coupled to an end of the tubular liner, wherein the tubular liner includes one or more expandable tubular members that each include a tubular body comprising an intermediate portion and first and second expanded end portions coupled to opposing ends of the intermediate portion, and a sealing member coupled to the exterior surface of the intermediate portion, and one or more other tubular members coupled to the expandable tubular members, wherein the inside diameters of the other tubular members are greater than or equal to the outside diameter of the tubular expansion cone. In an exemplary embodiment, the wall thicknesses of the first and second expanded end portions are greater than the wall thickness of the intermediate portion. In an exemplary embodiment, each expandable tubular member further includes a first tubular transitionary member coupled between the first expanded end portion and the intermediate portion, and a second tubular transitionary member coupled between the second expanded end portion and the intermediate portion, wherein the angles of inclination of the first and second tubular transitionary members relative to the intermediate portion ranges from about 0 to 30 degrees. In an exemplary embodiment, the outside diameter of the intermediate portion ranges from about 75 percent to about 98 percent of the outside diameters of the first and second expanded end portions. In an exemplary embodiment, the burst strength of the first and second expanded end portions is substantially equal to the burst strength of the intermediate tubular section. In an exemplary embodiment, the ratio of the inside diameters of the first and second expanded end portions to the interior diameter of the intermediate portion ranges from about 100 to 120 percent. In an exemplary embodiment, the relationship between the wall thicknesses t₁, t₂, and t_(INT) of the first expanded end portion, the second expanded end portion, and the intermediate portion, respectively, of the expandable tubular members, the inside diameters D₁, D₂ and D_(INT) of the first expanded end portion, the second expanded end portion, and the intermediate portion, respectively, of the expandable tubular members, and the inside diameter D_(wellbore) of the wellbore casing that the expandable tubular member will be inserted into, and the outside diameter D_(cone) of the expansion cone that will be used to radially expand the expandable tubular member within the wellbore casing is given by the following expression:

${{{Dwellbore} - {2*t_{1}}} \geq D_{1} \geq {\frac{1}{t_{1}}\left\lbrack {{\left( {t_{1} - t_{INT}} \right)*D_{cone}} + {t_{INT}*D_{INT}}} \right\rbrack}};$

wherein t₁=t₂; and wherein D₁=D₂. In an exemplary embodiment, the tapered end of the tubular expansion cone includes a plurality of adjacent discrete tapered sections. In an exemplary embodiment, the angle of attack of the adjacent discrete tapered sections increases in a continuous manner from one end of the tubular expansion cone to the opposite end of the tubular expansion cone. In an exemplary embodiment, the tapered end of the tubular expansion cone includes an paraboloid body. In an exemplary embodiment, the angle of attack of the outer surface of the paraboloid body increases in a continuous manner from one end of the paraboloid body to the opposite end of the paraboloid body. In an exemplary embodiment, the tubular liner includes a plurality of expandable tubular members, and the other tubular members are interleaved among the expandable tubular members.

A method of lining a wellbore casing has also been described that includes positioning a tubular liner within the wellbore casing, and radially expanding one or more discrete portions of the tubular liner into engagement with the wellbore casing. In an exemplary embodiment, a plurality of discrete portions of the tubular liner are radially expanded into engagement with the wellbore casing. In an exemplary embodiment, the remaining portions of the tubular liner are not radially expanded. In an exemplary embodiment, the discrete portions of the tubular liner are radially expanded by injecting a fluidic material into the tubular liner. In an exemplary embodiment, the tubular liner includes a plurality of tubular members; and wherein one or more of the tubular members are radially expanded into engagement with the wellbore casing and one or more of the tubular members are not radially expanded into engagement with the wellbore casing. In an exemplary embodiment, the tubular members that are radially expanded into engagement with the wellbore casing include a portion that is radially expanded into engagement with the wellbore casing and a portion that is not radially expanded into engagement with the wellbore casing. In an exemplary embodiment, the tubular liner includes one or more expandable tubular members that each include a tubular body comprising an intermediate portion and first and second expanded end portions coupled to opposing ends of the intermediate portion, and a sealing member coupled to the exterior surface of the intermediate portion, and one or more other tubular members coupled to the expandable tubular members, wherein the inside diameters of the other tubular members are greater than or equal to the maximum inside diameters of the expandable tubular members. In an exemplary embodiment, the tubular liner includes a plurality of expandable tubular members, and the other tubular members are interleaved among the expandable tubular members.

A system for lining a wellbore casing has also been described that includes means for positioning a tubular liner within the wellbore casing, and means for radially expanding one or more discrete portions of the tubular liner into engagement with the wellbore casing. In an exemplary embodiment, a plurality of discrete portions of the tubular liner are radially expanded into engagement with the wellbore casing. In an exemplary embodiment, the remaining portions of the tubular liner are not radially expanded. In an exemplary embodiment, the discrete portions of the tubular liner are radially expanded by injecting a fluidic material into the tubular liner. In an exemplary embodiment, the tubular liner includes a plurality of tubular members; and wherein one or more of the tubular members are radially expanded into engagement with the wellbore casing and one or more of the tubular members are not radially expanded into engagement with the wellbore casing. In an exemplary embodiment, the tubular members that are radially expanded into engagement with the wellbore casing comprise a portion that is radially expanded into engagement with the wellbore casing and a portion that is not radially expanded into engagement with the wellbore casing.

An apparatus has also been described that includes a subterranean formation defining a borehole, a casing positioned in and coupled to the borehole, and a tubular liner positioned in and coupled to the casing at one or more discrete locations. In an exemplary embodiment, the tubular liner is coupled to the casing at a plurality of discrete locations. In an exemplary embodiment, the tubular liner is coupled to the casing by a process that includes positioning the tubular liner within the casing, and radially expanding one or more discrete portions of the tubular liner into engagement with the casing. In an exemplary embodiment, a plurality of discrete portions of the tubular liner are radially expanded into engagement with the casing. In an exemplary embodiment, the remaining portions of the tubular liner are not radially expanded. In an exemplary embodiment, the discrete portions of the tubular liner are radially expanded by injecting a fluidic material into the tubular liner. In an exemplary embodiment, the tubular liner includes a plurality of tubular members; and wherein one or more of the tubular members are radially expanded into engagement with the casing and one or more of the tubular members are not radially expanded into engagement with the casing. In an exemplary embodiment, the tubular members that are radially expanded into engagement with the casing comprise a portion that is radially expanded into engagement with the casing and a portion that is not radially expanded into engagement with the casing. In an exemplary embodiment, the tubular liner includes one or more expandable tubular members that each include a tubular body comprising an intermediate portion and first and second expanded end portions coupled to opposing ends of the intermediate portion, and a sealing member coupled to the exterior surface of the intermediate portion, and one or more other tubular members coupled to the expandable tubular members, wherein the inside diameters of the other tubular members are greater than or equal to the maximum inside diameters of the expandable tubular members. In an exemplary embodiment, the tubular liner includes a plurality of expandable tubular members, and the other tubular members are interleaved among the expandable tubular members.

It is understood that variations may be made in the foregoing without departing from the scope of the invention. For example, the system 10 may be used to form or repair a wellbore casing, an underground pipeline, a structural support, or a tubing. Furthermore, the system 10 may include one or more expandable tubular members and one or more other tubular members. In addition, the system 10 may include a plurality of expandable tubular members, and the other tubular members may be interleaved among the expandable tubular members.

Although illustrative embodiments of the invention have been shown and described, a wide range of modification, changes and substitution is contemplated in the foregoing disclosure. In some instances, some features of the present invention may be employed without a corresponding use of the other features. Accordingly, it is appropriate that the appended claims be construed broadly and in a manner consistent with the scope of the invention. 

1. A system for lining a wellbore casing, comprising: a tubular support member defining a first passage; a tubular expansion cone defining a second passage fluidicly coupled to the first passage, coupled to an end of the tubular support member, and comprising a tapered end; a tubular liner coupled to and supported by the tapered end of the tubular expansion cone; and a shoe defining a valveable passage coupled to an end of the tubular liner; wherein the tubular liner comprises: one or more expandable tubular members that each comprise: a first tubular portion, a second tubular portion, and an intermediate tubular portion coupled between the first and second tubular portions; and a sealing member coupled to the exterior surface of the intermediate tubular portion; wherein the inside diameters of the first and second tubular portions are greater than the inside diameter of the intermediate tubular portion.
 2. The system of claim 1, wherein the wall thicknesses of the first and second tubular portions are greater than the wall thickness of the intermediate tubular portion.
 3. The system of claim 1, wherein each expandable tubular member further comprises: a first tubular tapered transitionary portion coupled between the first tubular portion and the intermediate tubular portion; and a second tubular tapered transitionary portion coupled between the second tubular portion and the intermediate tubular portion; wherein the angles of inclination of the first and second tapered tubular transitionary portions relative to the intermediate tubular portion ranges from greater than 0 to about 30 degrees.
 4. The system of claim 1, wherein the outside diameter of the intermediate tubular portion ranges from about 75 percent to about 98 percent of the outside diameters of the first and second tubular portions.
 5. The system of claim 1, wherein the burst strength of the first and second tubular portions is substantially equal to the burst strength of the intermediate tubular portion.
 6. The system of claim 1, wherein the ratio of the inside diameters of the first and second tubular portions to the interior diameter of the intermediate tubular portion ranges from greater than 100 to about 120 percent.
 7. The system of claim 1, wherein the relationship between the wall thicknesses t₁, t₂, and t_(INT) of the first tubular portion, the second tubular portion, and the intermediate tubular portion, respectively, of the expandable tubular members, the inside diameters D₁, D₂ and D_(INT) of the first tubular portion, the second tubular portion, and the intermediate tubular portion, respectively, of the expandable tubular members, and the inside diameter D_(wellbore) of the wellbore casing that the expandable tubular members will be inserted into, and the outside diameter D_(cone) of the tubular expansion cone that will be used to radially expand the expandable tubular members within the wellbore casing is given by the following expression: ${{{Dwellbore} - {2*t_{1}}} \geq D_{1} \geq {\frac{1}{t_{1}}\left\lbrack {{\left( {t_{1} - t_{INT}} \right)*D_{cone}} + {t_{INT}*D_{INT}}} \right\rbrack}};$ wherein t₁=t₂; and wherein D₁=D₂.
 8. The system of claim 1, wherein the tapered end of the tubular expansion cone comprises: a plurality of adjacent discrete tapered sections.
 9. The system of claim 8, wherein the angle of attack of the adjacent discrete tapered sections increases in a continuous manner from one end of the tubular expansion cone to the opposite end of the tubular expansion cone.
 10. The system of claim 1, wherein the tapered end of the tubular expansion cone comprises: a paraboloid body.
 11. The system of claim 10, wherein the angle of attack of the outer surface of the paraboloid body increases in a continuous manner from one end of the paraboloid body to the opposite end of the paraboloid body.
 12. The system of claim 1, wherein the tubular liner comprises a plurality of expandable tubular members and a plurality of other tubular members; and wherein the other tubular members are interleaved among the expandable tubular members. 